(11) Oil and Gas Producing Activities (Unaudited)

The Company's oil and gas exploration and production activities are conducted in Texas and the south central region of the United States, primarily along the Gulf Coast of Texas and Louisiana.

Oil and Gas Producing Activities -

Total costs incurred in oil and gas exploration and development activities, all incurred within the United States, were as follows (in thousands):

	Years Ended December 31,
	2011		2010		2009
Property acquisition costs
Unproved	$	3,591	$	2,295	$	6,199
Proved		-		-		-
Exploration costs
Expensed		9,166		3,233		3,818
Capitalized		-		-		1,035
Development costs		12,133		6,233		2,341
Total costs incurred	$	24,890	$	11,761	$	13,393

The aggregate capitalized costs relative to oil and gas producing activities are as follows (in thousands):

	December 31,
	2011			2010
Unproved oil and gas properties	$	7,291		$	12,250
Proved oil and gas properties		74,376			69,011
		81,667			81,261
Accumulated depreciation, depletion
and amortization		(55,061	)		(51,857	)
Net capitalized cost	$	26,606		$	29,404

Estimated Oil and Natural Gas Reserves -

The following information regarding estimates of the Company's proved oil and gas reserves, all located in Texas and the south central region of the United States, is based on reports prepared on behalf of the Company by its independent petroleum engineers. Because oil and gas reserve estimates are inherently imprecise and require extensive judgments of reservoir engineering data, they are generally less precise than estimates made in conjunction with financial disclosures. The revisions of previous estimates as reflected in the table below result from changes in commodity pricing assumptions and from more precise engineering calculations based upon additional production histories and price changes.

Proved developed and undeveloped reserves are presented as follows (in thousands):

	Years Ended December 31,
	2011						2010						2009
	Natural						Natural						Natural
	Gas			Oil			Gas			Oil			Gas			Oil
	(Mcf's)			(Bbls.)			(Mcf's)			(Bbls.)			(Mcf's)			(Bbls.)
Total proved reserves-
Beginning of year		7,794			267			7,248			242			6,443			230
Revisions of previous estimates		(520	)		(24	)		(832	)		-			(129	)		(4	)
Oil and gas reserves sold		(2,148	)		(26	)		-			-			-			-
Extensions, discoveries and
Other reserve additions		6,430			137			2,743			79			2,238			66
Production		(1,895	)		(62	)		(1,365	)		(54	)		(1,304	)		(50	)
End of year		9,661			292			7,794			267			7,248			242

The components of proved oil and gas reserves for the three years ended December 31, 2011 is presented below. All reserves are in the United States (in thousands):

	Years Ended December 31,
	2011				2010				2009
	Natural				Natural				Natural
	Gas		Oil		Gas		Oil		Gas		Oil
	(Mcf's)		(Bbls.)		(Mcf's)		(Bbls.)		(Mcf's)		(Bbls.)
Proved developed reserves		9,433		277		7,134		240		6,295		242
Proved undeveloped reserves		228		15		660		27		953		-
Total proved reserves		9,661		292		7,794		267		7,248		242

Proved undeveloped reserves originated in 2009 when active drilling efforts commenced and such period identified and delineated additional reserve acreage. During 2010 drilling efforts continued identifying additional reserve acreage and converting such undeveloped reserves to the developed category. Drilling in 2011 continued to develop the reserve acreage.

The Company has developed internal policies and controls for estimating and recording oil and gas reserve data. The estimation and recording of proved reserves is required to be in compliance with SEC definitions and guidance. The Company assigns responsibility for compliance in reserve bookings to the office of President of the Company's AREC subsidiary. No portion of this individual's compensation is directly dependent on the quantity of reserves booked. Reserve estimates are required to be made by qualified reserve estimators, as defined by Society of Petroleum Engineers' Standards.

The Company employs third party petroleum consultant, Ryder Scott Company, to prepare its oil and gas reserve data estimates as of December 31, 2011, 2010 and 2009. The firm of Ryder Scott is well recognized within the industry for more than 50 years. As prescribed by the SEC, such proved reserves were estimated using 12-month average oil and gas prices, based on the first-day-of-the-month price for each month in the period, and year-end production and development costs for each of the years presented, all without escalation.

The process of estimating oil and gas reserves is complex and requires significant judgment. Uncertainties are inherent in estimating quantities of proved reserves, including many factors beyond the estimator's control. Reserve engineering is a subjective process of estimating subsurface accumulations of oil and gas that cannot be measured in an exact manner, and the accuracy of any reserve estimate is a function of the quality of available data and the interpretation thereof. As a result, estimates by different engineers often vary, sometimes significantly. In addition, physical factors such as the results of drilling, testing and production subsequent to the date of an estimate, as well as economic factors such as changes in product prices, may justify revision of such estimates. Accordingly, oil and gas quantities ultimately recovered will vary from reserve estimates.

Standardized Measure of Discounted Future Net Cash Flows from Oil and Gas Operations and Changes Therein -

The standardized measure of discounted future net cash flows was determined based on the economic conditions in effect at the end of the years presented, except in those instances where fixed and determinable gas price escalations are included in contracts. The disclosures below do not purport to present the fair market value of the Company's oil and gas reserves. An estimate of the fair market value would also take into account, among other things, the recovery of reserves in excess of proved reserves, anticipated future changes in prices and costs, a discount factor more representative of the time value of money and risks inherent in reserve estimates. The standardized measure of discounted future net cash flows is presented as follows (in thousands):

	Years Ended December 31,
	2011			2010			2009
Future gross revenues	$	73,626		$	61,311		$	43,498
Future costs -
Lease operating expenses		(19,788	)		(17,288	)		(15,969	)
Development costs		(2,198	)		(1,596	)		(2,495	)
Future net cash flows before income taxes		51,640			42,427			25,034
Discount at 10% per annum		(19,439	)		(16,777	)		(10,719	)
Discounted future net cash flows
before income taxes		32,201			25,650			14,315
Future income taxes, net of discount at
10% per annum		(11,270	)		(8,978	)		(5,010	)
Standardized measure of discounted
future net cash flows	$	20,931		$	16,672		$	9,305

The reserve estimates provided at December 31, 2011, 2010 and 2009 are based on aggregate prices of $95.85, $76.14 and $58.43 per barrel for crude oil and $4.69, $5.26 and $4.05 per mcf for natural gas, respectively. Such prices reflect the unweighted arithmetic average of the prices in effect on the first day of the month for each month of the respective twelve month periods as required by Securities & Exchange Commission regulations. The affect of income taxes and discounting on the standardized measure of discounted future net cash flows is presented as follows (in thousands):

	Years ended December 31,
	2011			2010			2009
Future net cash flows before income taxes	$	51,640		$	42,427		$	25,034
Future income taxes		(18,074	)		(14,849	)		(8,762	)
Future net cash flows		33,566			27,578			16,272
Discount at 10% per annum		(12,635	)		(10,906	)		(6,967	)
Standardized measure of discounted
future net cash flows	$	20,931		$	16,672		$	9,305

The principal sources of changes in the standardized measure of discounted future net flows are as follows (in thousands):

	Years Ended December 31,
	2011			2010			2009
Beginning of year	$	16,672		$	9,305		$	11,547
Sale of oil and gas reserves		(7,429	)		-			-
Net change in prices and production costs		791			9,435			(4,890	)
New field discoveries and extensions, net of future
production costs		18,769			9,068			3,471
Sales of oil and gas produced, net of production costs		(7,723	)		(7,084	)		(5,114	)
Net change due to revisions in quantity estimates		(1,739	)		(1,369	)		(347	)
Accretion of discount		1,678			1,072			1,242
Production rate changes and other		2,204			213			2,189
Net change in income taxes		(2,292	)		(3,968	)		1,207
End of year	$	20,931		$	16,672		$	9,305

Results of Operations for Oil and Gas Producing Activities -

The results of oil and gas producing activities, excluding corporate overhead and interest costs, are as follows (in thousands):

	Years Ended December 31,
	2011			2010			2009
Revenues	$	14,060		$	11,021		$	8,650
Costs and expenses -
Production		(6,337	)		(3,937	)		(3,536	)
Producing property impairment		(7,105	)		(946	)		(1,350	)
Exploration		(9,166	)		(3,233	)		(3,735	)
Depreciation, depletion and amortization		(8,246	)		(4,662	)		(3,654	)
Operating income (loss) before income taxes		(16,794	)		(1,757	)		(3,625	)
Income tax (expense) benefit		5,878			615			1,268
Operating income (loss)	$	(10,916	)	$	(1,142	)	$	(2,357	)